|Publication number||US7293616 B2|
|Application number||US 10/258,555|
|Publication date||Nov 13, 2007|
|Filing date||Apr 24, 2001|
|Priority date||Apr 25, 2000|
|Also published as||CA2405970A1, CA2405970C, DE60127112D1, DE60127112T2, EP1276954A1, EP1276954B1, US20030183424, WO2001081708A1|
|Publication number||10258555, 258555, PCT/2001/1814, PCT/GB/1/001814, PCT/GB/1/01814, PCT/GB/2001/001814, PCT/GB/2001/01814, PCT/GB1/001814, PCT/GB1/01814, PCT/GB1001814, PCT/GB101814, PCT/GB2001/001814, PCT/GB2001/01814, PCT/GB2001001814, PCT/GB200101814, US 7293616 B2, US 7293616B2, US-B2-7293616, US7293616 B2, US7293616B2|
|Inventors||Rory McCrae Tulloch|
|Original Assignee||Weatherford/Lamb, Inc.|
|Export Citation||BiBTeX, EndNote, RefMan|
|Patent Citations (28), Non-Patent Citations (1), Referenced by (38), Classifications (8), Legal Events (4)|
|External Links: USPTO, USPTO Assignment, Espacenet|
The present invention relates to a drill bit primarily for use in creating well bores, but which can also be used inside liner casing to remove build-ups of scale.
The drilling of wells for oil and gas production is achieved using a string of drill pipe with a drill bit mounted at the lowermost end, which is rotated from the surface into the earth. The drill bit is generally comprised of a body which can be secured to a work string at its uppermost end, ie the shank, and a crown. The crown is essentially the area of the bit which carries the cutting means which drill the earth to create the bore, and is comprised of an uppermost chamfer, an annular gauge and tapered flank upon which the cutting means are mounted, and a lowermost nose which engages with the bottom of the hole.
After a section of well has been bored, it is common practice to insert joints of heavy steel tubing, commonly known as casing, into the bore to act as a liner to structurally support the walls of the well bore from collapse.
Typically, the casing has a smaller outside diameter than the drill bit which created the bore into which the casing is to be passed.
The standard method used to drill well bores is to drill each section with consecutively smaller bits and then line the well bores with proportionately smaller casing. However, a standard practice also exists with regard to using a drilling underreamer positioned behind a standard drill bit acting as a pilot to cut the inner cross-sectional area of the well bore. Conventional underreamers include a number of expandable arms which can move between a withdrawn or closed configuration and an expanded or open configuration. The pilot bit and underreamer can be passed through the casing when the underreamer is closed. After passing through the casing the underreamer can be opened in order to enlargen the rat-hole below the casing shoe, and hence create a wellbore equal to or larger than the original drilled hole. In recent years bi-centre bits, which have offset cutting members mounted at irregular intervals around the crown of the bit, have been developed as an alternative to underreamers. However, these bits are unstable due to their irregular structure and tend to be more difficult to control for directional purposes than ordinary drill bits and may not drill the expected swept diameter of the offset pads which ream the pilot hole created by the crown.
It will be appreciated that it is not always desirable, or in fact possible to drill a truly straight well bore. For example it may be desirable to control the direction of the drilling procedure in order to reach a particular area, or to create a horizontal or expanded well once the correct depth of bore has been drilled. In such instances, it is common to use steerable drilling apparatus. Standard steerable drilling apparatus is generally comprised of a downhole motor which can drive or rotate a drill bit positioned at the lowermost end of the motor. Typically, the downhole motor has a bent housing with an angle of 0.5 to 2.0 degrees above the bearing section of the motor about 6-10 feet behind the bit. This can be used to steer the assembly when the drill-string is not being rotated and allows the direction of the well-bore to be controlled in response to changing downhole conditions. In order to steer the drill bit in a desired direction, rotation of the drill string is stopped which allows the motor to incline the drill bit to tilt in the desired direction. As a result, a curved section of the bore can be formed. At other times the drill string is rotated as normal, which negates the action of the downhole motor bent housing on the drill bit.
In general, underreamers and bi-centre bits are not designed for high accuracy open hole directional drilling with steerable downhole motors or rotary steerable systems. Steerable drilling requires the drill bit which is utilised to be able to change the direction of the drilled well bore quickly when being tilted or a side force is applied. Underreamers have a large spacing between the pilot bit and the expandable arms and therefore do not permit this rapid directional change to take place. Bi-centre bits are designed such that the distance between the crown and offset pads is relatively large, and as a consequence these bits are not as steerable as ordinary short gauge bits.
It is recognised in the present invention that it would be an advantage to provide a truly expandable drill bit which is small enough such that it can be passed through a small diameter bore or casing in one mode and then can be expanded such that it can drill a larger diameter hole below the restriction it has passed through in a second mode, but wherein the drill bit is designed such that it has a sufficiently short gauge length to be used in a variety of drilling operations including steerable drilling applications.
It is therefore an object of the present invention to provide a truly expandable drill bit which can be used with steerable downhole motors or rotary steerable systems.
It is a further object of the present invention to provide an expandable drill bit which, when expanded, has a short gauge length and a crown profile with a shape common to solid crown bit, and therefore has the same steerability as conventional steerable solid crown drill bits.
According to the present invention there is provided an expandable drill bit for use with earth drilling equipment, wherein the drill bit is comprised of a body having two or more arms, the arms being provided by the crown of the drill bit having a split crown profile, wherein the arms support a plurality of cutting elements and are hingeably attached to the body, and wherein the arms are moveable between a first and second position, wherein the arms are closed in the first position and expanded in the second position.
Preferably, when the arms are in the second expanded position, the drill bit has a short gauge length and the profile of the expanded crown is similar to that of a steerable solid crown bit.
Preferably, movement of the arms from the first closed position to the second expanded position is provided by virtue of the movement of an actuating shaft.
In one preferred embodiment movement of the actuating shaft in a downward direction drives the arms from the first closed position to the second expanded position.
In an alternative embodiment, movement of the actuating shaft in an upward direction lifts the arms from the first closed position to the second expanded position.
The first embodiment is preferred as the actuating shaft can be used to support the arms to a greater degree. Also the bit nozzles can be placed closer to the cutters for greater hydraulic effect and the thrust area and hence the axial thrust acting on the actuating shaft to push the arms open can be made much greater, while minimising the overall length of the bit for greater steerability.
Preferably movement of the actuating member is driven by a hydrodynamic pressure drop.
Most preferably said hydrodynamic pressure drop is created by one or more nozzles which may be attached to the lowermost end of the actuating member.
Preferably the one or more nozzles communicate with a through bore defined by the actuating member.
Preferably the actuating member has an external upset at its lowermost end which supports the arms when closed in the first position, and drives the arms to the second expanded position upon the application of hydraulic pressure created by directing mud flowing through the ports or nozzles in the actuating member.
Preferably the arms have an internal profile which communicates with the upset end of the actuating member such that the upset end of the actuating member supports the arms both in the first closed position and in the second expanded position.
Preferably the drill bit is adapted for use with steerable drilling apparatus. The steerable drilling apparatus may include a downhole motor.
In one embodiment the arms are driven from the second expanded position to the first closed position by the action of return springs.
Optionally a first return spring is a heavy duty helical coil spring.
Alternatively a stack of disc springs can be utilised as the first return spring.
Preferably a second return spring comprises a single coil split ring.
Preferably the second return spring is located externally to the arms.
In a second embodiment the arms are pulled together from the second expanded position to the first closed position with the aid of both secondary return springs, wherein the springs are located internally to the arms.
Preferably the cutting elements comprise one or more rows of cutters on each arm.
Typically the cutters are made from a hard material such as diamond or tungsten carbide.
Preferably the cutters are arranged to form a double row of cutters in the centre of the bit, ie at least two of the arms overlap when in the closed position and when in the second expanded position the cutters will cut the full swept area out to the expanded gauge diameter.
Optionally the arms may include a sensor to detect if the arms are out to the gauge diameter intended. The sensor activation can also confirm that the arm is still in place, ie has not been torn off.
Preferably said sensor is in the form of an electrical switch to complete a circuit and one would preferably be used for each arm.
Optionally the drill bit may contain a sensor which registers the travel of the actuating shaft or the actuating shaft coupling.
Embodiments of the present invention will now be illustrated, by way of example, with reference to the following Figures in which:
Referring firstly to
Nozzles 9 are attached to the lowermost end of the actuating shaft 3 and communicate with a fluid through bore 10 which is defined by the body of the actuating shaft 3. The nozzles 9 may be permanently or detachably fixed to the actuating shaft 3 to allow the jetting of drilling fluid. In the depicted embodiment a total of four nozzles 9 are fitted to the actuating shaft 3 although it is recognised that the number of nozzles 9 which can be fitted is not limited, and is restricted only by the space constraints of the size of the actuating shaft 3. The nozzles 9 are used for standard jetting of the bit face when drilling, to remove any cutting build up which may gather immediately in front of the actuating member 3 and arms 6 and 7, and also to supply a hydraulic pressure drop which moves the actuating shaft 3.
The arms 6 and 7 of the drill bit 1 can move between a first position shown in
In the described embodiment the hydrodynamic pressure drop causes the actuating member 3 to move in a downward direction where it engages with an internal profile shoulder 12 on the arms 6 and 7 to expand them outwardly from the body 2 of the drill bit 1. However it is recognised that in an alternative embodiment of the present invention the actuating shaft 3 may be adapted to be driven in an upward direction by the pressure drop, wherein upon moving upwards, the actuating member 3 lifts the arms 6 and 7 into an expanded open configuration.
The actuating shaft 3 is prevented from rotating with respect to the body 2 by four (by way of example) pins so that the nose of the actuating shaft will strengthen the four arms when torque is applied to them. A spline could also be used. The nose of the actuating shaft 3 has a milled profile to support the arms with respect to torque applied when drilling.
The back of the arms 6 and 7 is designed such that it has a low angle with respect to the hole diameter. This allows maximum force to be applied in the event that the arms 6 and 7 stick in the second expanded position so that when the drill bit 1 is pulled up against the casing shoe(not shown) the arms 6 and 7 will be driven back against the body 2 of the drill bit 1 with maximum force. This tapered surface could also have cutters fitted for back-reaming when pulling out of hole.
It will be appreciated that at some point prior to running the apparatus it may be necessary to check the size of the nozzles 9 in order to determine whether they suit the required downhole hydraulics for the run. In the preferred embodiment the drill bit 1 will be nozzled such that the arms 6 and 7 begin to extend at a minimum hydrodynamic pressure of approximately 100 psi and be fully expanded by 200 psi, although it will be appreciated that these pressures could be varied for the particular drilling application and conditions. This allows a minimum circulation to be run through the bit 1 for lubrication, without expanding the arms 6 and 7.
In order to change the nozzles 9 prior to use, a threaded rod 13 already screwed into a coupling is inserted into the fluid through bore 10 of the drill bit 1, as can be seen in
In order to allow the drill bit 1 to pass through restrictions, such as a narrow diameter bore or in-place casing, it is necessary for the arms 6 and 7 of the drill bit 1 to be closed. This is achieved by way of two springs which drive the arms 6 and 7 back into the body 2. The first spring 14 is an internal heavy duty helical coil spring whilst the second is a single coil split ring 15 which is mounted around the outside of the four arms 6 and 7, in the area just outside the hinge pins 5. The second spring 15 adds a more positive return force directly to the arms 6 and 7 when the actuating member 3 returns to the position shown in
It is recognised that although the springs are located external to the arms 6 and 7 in the described embodiment, in an alternative embodiment two or more springs could be used on the inside of the arms 6 and 7 which pull them together. Further, the first spring could alternatively be a stack of disc springs.
The hinges 5 are positioned between the body 2 of the tool and the arms (not shown), each arm being attached to a hinge 5 which allows the arm to expand away from the body 2 upon movement of the actuating shaft 3.
Note also that each pair of arms could be linked via a guide pin with one of the arms having a pin rigidly fitted with a slot in the adjacent mating arm.
The drill bit 1 also preferably comprises low friction piston seals which may be PTFE seals with O ring energisers, between the body 2 and the shaft 3, which minimise the force available from the coil spring 15 to return the actuating shaft 3. In a preferred embodiment the bore 10 of the body 2 has a corrosion resistant coating or treatment so that the seals run on a smooth surface.
Expandable bit 1A is now such that the drilling load applied to the bit is taken entirely through the inner mandrel/actuating shaft 3A. This means that the application of drilling weight to the bit now keeps the arms 6A, 7A in the expanded position in addition to the hydraulic force acting on an internal piston 18.
The tool 1A is hydraulically actuated due to the pressure drop created by throttling the flow of drilling fluid by the nozzles 9A in the head 16 of the bit. Simply applying drilling weight to the tool 1A in the closed position would also tend to expand the arms 6A, 7A, but is not a principal operating feature.
Internal hydraulic pressure is applied to the chamber 17 above the piston 18 mounted on the inner mandrel 3A by means of radial drilled holes 19 in the mandrel 3A. The force created moves the outer cylinder 2A axially upwards, compressing the spring 14A and drawing the arms 6A, 7A upwards over the profile of the head 16 into the expanded position.
The arms 6A, 7A are now constrained within slots 20 in the head for greater rigidity. Guide pins 21 act on slots 20 machined in the arms 6A, 7A to ensure that the arms 6A, 7A return to the closed position on removal of the pressure differential, as described hereinbefore. Note that a secondary spring is no longer used to close the arms 6A, 7A.
An additional feature of the second embodiment of bit 1A is that pulling upwards on the tool 1A will tend to drag the external sleeve 2A downwards, thus moving the arms 6A, 7A to the closed position.
A further feature of the second embodiment of bit 1A includes two sensors 22, 23.
Arms 6A and 7A are fitted with sensors 22A-D. Sensors 22A-D are electronic sensors, which signal when the arms 6A and 7A are out at gauge size. This signal is sent back into an MWD tool behind the bit 1A or may be an instrumented downhole motor, and then transmitted directly to the surface, so that the operator is aware of the configuration of the bit 1A as it is run downhole. The sensors 22A-D being activated would also confirm the arms 6A and 7A are still in position ie have not been torn off. Sensor 23 is also fitted to bit 1A. Sensor 23 registers the movement of the actuating shaft 3A.
The advantage of the present invention over the prior art is that there is provided a truly expandable drill bit, in contrast to an offset bi-centre bit or an underreamer for use in conjunction with a standard drill bit. The expandable drill bit is therefore characterised in that it has all the proven characteristics of a standard steerable drill bit, most notably a short gauge length with a standard crown profile shape and can be used with steerable drilling apparatus, but also has a variable diameter which facilitates the passage of the drill bit through an area of a well bore or casing with a restricted diameter in order to drill a section of bore with a greater diameter, below the restricted area.
Further modifications and improvements may be incorporated without departing from the scope of the invention herein intended.
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|U.S. Classification||175/269, 175/383, 175/267, 175/384|
|International Classification||E21B10/32, E21B10/62|
|Jun 3, 2003||AS||Assignment|
Owner name: WEATHERFORD/LAMB, INC., TEXAS
Free format text: ASSIGNMENT OF ASSIGNORS INTEREST;ASSIGNOR:TULLOCH, RORY MCCRAE;REEL/FRAME:014234/0504
Effective date: 20021202
|Apr 14, 2011||FPAY||Fee payment|
Year of fee payment: 4
|Dec 4, 2014||AS||Assignment|
Owner name: WEATHERFORD TECHNOLOGY HOLDINGS, LLC, TEXAS
Free format text: ASSIGNMENT OF ASSIGNORS INTEREST;ASSIGNOR:WEATHERFORD/LAMB, INC.;REEL/FRAME:034526/0272
Effective date: 20140901
|Apr 29, 2015||FPAY||Fee payment|
Year of fee payment: 8